EP3019896B1 - Reconnaissance de la porosité et de la fraction d'huile par spectroscopie diélectrique - Google Patents

Reconnaissance de la porosité et de la fraction d'huile par spectroscopie diélectrique Download PDF

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EP3019896B1
EP3019896B1 EP13828893.1A EP13828893A EP3019896B1 EP 3019896 B1 EP3019896 B1 EP 3019896B1 EP 13828893 A EP13828893 A EP 13828893A EP 3019896 B1 EP3019896 B1 EP 3019896B1
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Prior art keywords
water
oil
porous medium
value
curve
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EP3019896A1 (fr
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Vitaly Nikolaevich Dorovsky
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Baker Hughes Holdings LLC
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Baker Hughes Holdings LLC
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    • G—PHYSICS
    • G01—MEASURING; TESTING
    • G01V—GEOPHYSICS; GRAVITATIONAL MEASUREMENTS; DETECTING MASSES OR OBJECTS; TAGS
    • G01V3/00—Electric or magnetic prospecting or detecting; Measuring magnetic field characteristics of the earth, e.g. declination, deviation
    • G01V3/18—Electric or magnetic prospecting or detecting; Measuring magnetic field characteristics of the earth, e.g. declination, deviation specially adapted for well-logging
    • G01V3/30—Electric or magnetic prospecting or detecting; Measuring magnetic field characteristics of the earth, e.g. declination, deviation specially adapted for well-logging operating with electromagnetic waves
    • G—PHYSICS
    • G01—MEASURING; TESTING
    • G01V—GEOPHYSICS; GRAVITATIONAL MEASUREMENTS; DETECTING MASSES OR OBJECTS; TAGS
    • G01V3/00—Electric or magnetic prospecting or detecting; Measuring magnetic field characteristics of the earth, e.g. declination, deviation
    • G01V3/38—Processing data, e.g. for analysis, for interpretation, for correction

Definitions

  • This disclosure generally relates to exploration and production of hydrocarbons involving investigations of regions of an earth formation penetrated by a borehole. More specifically, the disclosure relates to the dielectric spectroscopy of an earth formation using a logging tool in a borehole.
  • the present disclosure belongs to the second category.
  • one or more measurement electrodes - current source(s) or sink(s) - are used in conjunction with a return electrode (which may be a diffuse electrode such as a logging tool's body or mandrel).
  • a measurement current flows in a circuit that connects a current source to the measurement electrode(s), through the earth formation to the return electrode, and back to the current source in the tool.
  • an antenna within the measuring instrument induces a current flow within the earth formation. The magnitude of the induced current is detected using either the same antenna or a separate receiver antenna.
  • the present disclosure belongs to the second category.
  • WO 2013/012349 discloses methods and apparatuses for finding oil content of a formation using dielectric spectroscopy.
  • US 2007/061083 discloses a method for determining properties of earth formations using dielectric permittivity measurements.
  • WO 2014/014372 discloses methods and apparatuses for finding oil viscosity and surface tension by means of dielectric spectroscopy.
  • the present disclosure is directed to a method and apparatus for estimating at least one property using dielectric spectroscopy of subterranean formations penetrated by a borehole.
  • the present invention provides a method of evaluating an earth formation including a porous medium, as claimed in claim 1.
  • the present invention provides an apparatus for evaluating an earth formation, as claimed in claim 12.
  • Dielectric spectroscopy includes the estimation of electric permittivity of materials.
  • Electric permittivity may include imaginary and real parts, which may vary with the frequency of an electrical signal exposed to a material.
  • electric permittivity may be estimated using an electromagnetic tool configured to generated an electric current at a plurality of frequencies.
  • the electromagnetic tool may include an inductive electromagnetic probe that may be electrically coupled to an earth formation from inside of a borehole penetrating the earth formation.
  • Dielectric permittivity may be obtained by solving Maxwell's equations.
  • H z M z rz 4 ⁇ R 5 3 + 3 kR + k 2 R 2 e ⁇ kR
  • H ⁇ 0 0
  • H z 0 ⁇ M z 4 ⁇ R 3 3 r 2 R 2 + 3 kr 2 R + k 2 R 2 ⁇ 2 ⁇ 2 kR e ⁇ kR
  • R 2 r 2 + z 2
  • M z is the receiver coil magnetic moment
  • k is a wave number
  • ⁇ is a circular () frequency
  • R is a radial distance
  • r and z are coordinates in the cylindrical coordinate system
  • ⁇ is the permeability of the material
  • ⁇ ' and ⁇ " are real and imaginary parts of dielectric permittivity.
  • the dielectric permittivity may be estimated using methods known to those of skill in the art, including, but not limited to one or more of: (i) a Newton method and (ii) a Marquardt-Levenberg method.
  • the estimated imaginary and real parts of permittivity of the earth formation may be used to estimate at least one parameter of interest of the earth formation.
  • the at least one parameter of interest may include, but is not limited to: (i) water saturation, (ii) oil saturation, and (iii) percentage of oil; (iv) percentage of water; and (v) formation porosity.
  • a dipole antenna configured to emit electromagnetic waves is placed in the center of the borehole with a receiver antenna located in the borehole at a certain distance from the transmitter, then real and imaginary parts of the magnetic field may be measured by the receiver antenna.
  • a spectral image of dielectric permittivity may be generated using the imaginary and real parts of permittivity over a plurality of frequencies.
  • the spectral image may also be referred to as a "spectral dielectric curve" and a "polarization curve”.
  • Each point on the spectral image of dielectric permittivity may correspond to a specific frequency in the electromagnetic spectrum.
  • the bulk fractions of water and oil in the earth formation may be estimated using the spectral image of dielectric permittivity.
  • aspects of the present disclosure include using a borehole inductive electromagnetic tool to measure the real and imaginary parts of the dielectric spectrum at a fixed borehole depth. This may include estimating all spectral characteristics of the H192iak-Negami curve. The percentage of oil contained in the formation pores may be estimated from oil and / or water saturation characteristics using methods disclosed herein. Using the tabulated curves for sandstones, carbonates, etc. and the limit value of another polarization parameter, further aspects of the disclosure may enable estimation of the formation porosity. Example apparatus and method embodiments for estimating properties of the formation are discussed below.
  • FIG. 1 shows an electromagnetic tool 10 suspended, in a borehole 12 penetrating earth formation 13, from a suitable cable 14 that passes over a sheave 16 mounted on drilling rig 18.
  • the cable 14 includes a stress member and seven conductors for transmitting commands to the tool and for receiving data back from the tool as well as power for the tool.
  • the electromagnetic tool 10 is raised and lowered by draw works 20.
  • Electronic module 22, on the surface 23, transmits the required operating commands downhole and in return, receives data back which may be recorded on an archival storage medium of any desired type for concurrent or later processing.
  • the data may be transmitted in analog or digital form.
  • Data processors such as a suitable computer 24, may be provided for performing data analysis in the field in real time or the recorded data may be sent to a processing center or both for post processing of the data. Some or all of the processing may also be done by using a downhole processor at a suitable location on the logging tool 10. While a wireline conveyance system has been shown, it should be understood that embodiments of the present disclosure may be utilized in connection with tools conveyed via rigid carriers (e.g., jointed tubular or coiled tubing) as well as non-rigid carriers (e.g., wireline, slickline, e-line, etc.). Some embodiments of the present disclosure may be deployed along with LWD/MWD tools.
  • rigid carriers e.g., jointed tubular or coiled tubing
  • non-rigid carriers e.g., wireline, slickline, e-line, etc.
  • the electromagnetic tool 10 may include at least one transmitting antenna and at least two receiving loop antennas mounted on a pad.
  • the tool may be operated in at least two modes.
  • a first mode may be referred to as Mini-MPR (Multiple propagation resistivity) mode that may measure attenuation and a phase difference between the two receivers.
  • the electromagnetic tool 10 may also be operated in a second mode (an induction mode) in which a compensated magnetic field (voltage) may be measured.
  • the current in the transmitter coil may induce a magnetic field in the earth formation 13. This magnetic field, in turn, may cause eddy currents to flow in the earth formation 13. Because of the presence of these formation currents, a magnetic field may be coupled into a receiver coil R thereby generating a receiver signal.
  • Logging tools having "a receiver coil” and "a transmitter coil” each comprised of several coils arranged in a predetermined fashion to obtain a desired response may be used.
  • the receiver signal may then be amplified and applied to one or more phase sensitive detectors (PSDs).
  • PSDs phase sensitive detectors
  • Each PSD may detect a phase component signal having a phase identical to a phase reference signal which may also be applied to the detector.
  • the phase reference signal may have a predetermined phase relationship to the current in the transmitter coil(s).
  • the output of the PSD(s) may be further processed downhole, or may be sent uphole to surface equipment for processing or display to an operating engineer.
  • one receiver loop coil may serve as a main receiver and the other as a bucking receiver.
  • the transmitting antennas may include loops and/or electric dipoles.
  • the transmitters and receivers may be in one of three orientations. If the z-axis of the tool is parallel to the longitudinal axis of the tool, then the x-axis may be radial through the center of the pad, and the y-axis may be tangential to the pad.
  • the zz-component may refer to a z-source and a z-receiver and so on. In some embodiments, xx-transmitters and receivers may be used.
  • FIG. 2A shows an electromagnetic tool 10 for one embodiment according to the present disclosure.
  • the electromagnetic tool 10 may include a body 55 with two pads 51A, 51B extended on extension devices 53A, 53B. Two pads are shown for illustrative purposes and, in actual practice, there may be more pads.
  • the extension devices 53A, 53B may be electrically operated, electromechanically operated, mechanically operated or hydraulically operated. With the extension devices 53A, 53B fully extended, the pads 51A, 51B can make contact with the borehole wall (not shown) and make measurements indicative of properties of the borehole wall.
  • Orientation sensors (not shown) may provide an indication of the orientation of the electromagnetic tool 10.
  • cable depth measurements may be obtained using a sensor (not shown) at the surface that measures the amount of cable spooled out.
  • accelerometers may be used downhole to provide other measurements indicative of the depth of the electromagnetic tool 10.
  • the orientation sensors may include accelerometers, magnetometers or gyroscopes. Depth may also be estimated from a gy
  • FIG. 2B An exemplary arrangement of dual transmitters and receivers on each of the pads is shown in FIG. 2B . Shown therein is pad 51A with two transmitters 55A, 55B disposed about two receivers 57A, 57B. Also depicted schematically by arrows in FIG. 2B are measurements that may be made by each of the two receivers 57A, 57B corresponding to signals generated by each of the two transmitters 55A, 55B.
  • the use of dual transmitters may provide a symmetrical response.
  • the use of dual transmitters may also reduce effects of borehole rugosity.
  • the use of dual transmitters may reduce electronics-related errors in attenuation measurement. The electronics-related errors may not affect the phase difference measurement.
  • Averaging equations (3) and (4) may remove the effect of gain variation.
  • FIG. 3A shows a schematic of a generic tool configuration for one embodiment according to the present disclosure.
  • Pad 51A may include two receiver arrays 103A, 103B.
  • the coils 101A, 101B of the upper and lower receiver arrays may be aligned radially with respect to the tool axis (movement) direction.
  • the receiver coils 105 are separated laterally by a constant distance that is determined by the azimuthal resolution of the electromagnetic tool.
  • Two transmitting antennas 101 A, 101B may be placed above receiver array 103A and below receiver array 103B.
  • the transmitting antennas 101A, 101B may be operated one at a time during which measurements from each and every receiver pair are made.
  • An exemplary current flow direction for the transmitters 101A, 101B is shown by the arrows in FIG. 3A . With the indicated current flow of the transmitters 101A, 101B and the coil orientation of the receivers 105, the measurements made would be xx-measurements.
  • the measurements may include attenuation rate, phase difference, or compensated magnetic field.
  • FIG. 3B shows a schematic of another embodiment of a generic tool configuration with staggered receiver pairs according to the present disclosure.
  • the receiver pairs may be staggered in the tool axis direction, allowing a small separation between the receiver pairs.
  • the upper receiver array 103A' may comprise two staggered rows of receivers 105 and the lower receiver array 103B' may comprise two staggered rows of receivers 105 to reduce the gaps in azimuthal coverage of the configuration of FIG. 3A .
  • FIG. 4A is a schematic of a transmitter for one embodiment according to the present disclosure.
  • Transmitters 101A' and 101B' may have wires wound around the pad 51A.
  • the wire paths may be substantially normal to the tool axis, going in the front, back, and on sides of the pad 51A. With the configuration shown in FIG. 4A , the measurements would be zx-measurements.
  • FIG. 4B is a schematic of a transmitter for another embodiment according to the present disclosure.
  • Transmitters 101A", 101B" may be electric dipoles normal to the tool axis.
  • FIG. 5 is a flow chart of one method 500 for estimating a fluid saturation according to one embodiment of the present disclosure.
  • electromagnetic tool 51A may be conveyed in the borehole 12.
  • signals at a plurality of frequencies may be transmitted from transmitters 101A, 101B into the earth formation. In some embodiments, at least one of the plurality of frequencies may be at a frequency at or above 500 MHz.
  • receivers 103A, 103B may generate an output indicative the complex dielectric permittivity of the earth formation 13.
  • a rate of change of the imaginary part of the complex dielectric permittivity relative to the real part of the complex dielectric permittivity may be estimated using the generated output.
  • a fluid saturation may be estimated using the estimated rate of change.
  • the selection of the plurality of frequencies may include frequencies at or near the high frequency limit of the real part of dielectric permittivity for the particular polarization type of the earth formation.
  • Several basic polarization types depending on colloid structure of oil, water contact with the containing porous medium, and water-oil contact in the containing medium can be identified. The physical bases in these cases correspond to migration polarization (the Maxwell-Wagner polarization) at the contacts between colloid particles in oil, polarization of the double layer and bulk charge at the contacts between water and the rock matrix of the containing porous medium, etc.
  • Each polarization type may be identified with a specific structural unit of the medium and cataloged in the dielectric spectra. Determination of the particle type in the colloid solution in the porous medium may be then reduced to the problem of identification of the cataloged and the measured spectra. It should be noted that polarization types may be reduced to the following three basic polarization types.
  • FIG. 6 shows a set of complex permittivity curves depicting spectral images of dielectric permittivity for different relaxations related to polarization types and associated with colloidal structure of fluid within a saturated porous medium.
  • the Maxwell-Wagner relaxation determines the phase of colloid particles
  • the m-th power law relaxation corresponds to laminated or disk-shaped micellar colloid particles
  • the Debye relaxation corresponds to crystalline solid colloid particles
  • the Cole-Davidson relaxation corresponds to local crystalline structuring in colloid particles, etc.
  • the structure of water-oil mixture and colloid oil contents in the saturated porous medium may be identified.
  • the structure of the water-oil mixture may be indicative of permeability of the earth formation.
  • water-saturated sandstones and dolomites may have a polarization type that demonstrates Cole-Cole relaxation.
  • the polarization type may be identified using electromagnetic logging of the borehole.
  • fresh water-saturated porous media may be characterized by high dielectric permittivity (up to 10 3 -10 4 ) at characteristic relaxation frequencies.
  • FIG. 7 shows a chart with a set of curves representing the frequency dependence complex dielectric permittivity of sandstone saturated with (i) water and (ii) a mixture of water and transformer oil.
  • Curve 710 indicates the real part of dielectric permittivity for sandstone saturated with water.
  • Curve 720 indicates the imaginary part of dielectric permittivity for sandstone saturated with water.
  • Curve 730 indicates the real part of dielectric permittivity for sandstone saturated with a mixture of water and transformer oil.
  • Curve 740 indicates the imaginary part of dielectric permittivity for sandstone saturated with a mixture of water and transformer oil.
  • step 550 may include finding a bulk fraction of water if there is no oil and a bulk fraction of water in the presence of oil. The difference between these two values may yield the bulk fraction of oil.
  • the method of finding water saturation and oil saturation is illustrated below using the cases of the Cole-Cole relaxation and the HVeronicaiak-Negami relaxation.
  • the estimate of the dielectric permittivity may assume a natural porous medium, such as sandstone or dolomite, that is saturated with water and assuming that the dielectric polarization type of this system was established via borehole measurements.
  • FIG. 8 shows an exemplary set of curves for sandstone expressing complex dielectric permittivity over a range of frequencies.
  • the Cole-Cole relaxation is typically observed as shown in as curve 810.
  • ⁇ complex dielectric permittivity
  • ⁇ ⁇ the asymptotic value of the real part of this polarization type at high frequencies
  • ⁇ s is the static value of dielectric permittivity
  • ⁇ relaxation time
  • ⁇ is a parameter ranging from 0 to 1, which characterizes the polarization angle.
  • the distortion angles 830, 840 between each of the spectral dielectric curves 810, 820 and the x-axis may depend on the bulk fraction of the oil present in the formation. Distortion may be obtained from the spectral dependences of the dielectric constant (the real and imaginary parts) in the low frequency domain. Knowing the distortion angle, the bulk fraction of the oil present in the formation may be determined.
  • ⁇ max " ⁇ s ⁇ ⁇ ⁇ ⁇ tan 1 ⁇ ⁇ ⁇ / 4 / 2
  • ⁇ max " is the maximal loss factor
  • ⁇ s is the static value of the real part of dielectric
  • ⁇ ⁇ is its high-frequency limit
  • ⁇ is the polarization parameter
  • ⁇ ⁇ ( K ) is a given universal function of water saturation (water fraction in per cent).
  • the universal curve ⁇ ⁇ ( K %) may be obtained via laboratory experiments, and ⁇ max " , ⁇ max ′ , ⁇ may be obtained via inductive logging.
  • the polarization curve follows the H192iak-Negami formula as shown as curve 820 in FIG. 8 and expressed as follows.
  • ⁇ ⁇ ⁇ ⁇ + ⁇ s ⁇ ⁇ ⁇ 1 + i ⁇ 1 ⁇ ⁇ ⁇ where there are two polarization parameters: ⁇ and ⁇ .
  • ⁇ ⁇ ⁇ ⁇ , 0 + ⁇ s ⁇ ⁇ 1 / 2 + ...
  • the quadratic terms are to be taken into account.
  • water saturation may be calculated for the no-oil case K water using the right hand angle.
  • Polarization parameters ⁇ max " and ⁇ max ′ may be found via the right hand angle.
  • the Debye polarization (a special case of the Cole-Cole polarization with a single relaxation time of the corresponding distribution function) characterizes polarization in the system of independent oscillators in the external electric field. Asymmetry of the Debye polarization curve is related to the Cole-Davidson polarization curve. The physics behind this deformation of the polarization curve may be emerging non-linear interaction in the system of independent oscillators (polarizing dipoles in the external electric field). The analysis of the experimental spectral data for dielectric permittivity of the porous media saturated with water-oil mixture and for water-oil emulsions appears to indicate that, in the porous media, oil takes the form of droplets in water, i.e. a system similar to that of water-oil emulsions in the porous media.
  • ⁇ is relaxation time
  • ⁇ is the frequency of electromagnetic excitation of the medium
  • ⁇ and b are parameters characterizing the porous medium (0 ⁇ ⁇ ⁇ 1; 1 ⁇ b > 0).
  • the Cole-Cole diagram shows that the ⁇ "( ⁇ ') dependence has the form of an arc with an asymmetrically sloped left side ( FIG. 8 ).
  • the curve shows the spectral characteristics of the HVeronicaiak-Negami relaxation curve
  • Oil saturation ⁇ varies from 1 to ⁇ ⁇ .
  • the current value of ⁇ corresponds to the current value of ⁇ found for any v, as calculated above.
  • the parameter ⁇ may vary from 0 to ⁇ ⁇ , as is apparent from the graph.
  • ⁇ ⁇ 1 ⁇ 4 ⁇ arctg ⁇ ⁇ ⁇ .
  • Oil saturation corresponds to 1 - ⁇ with a possibility of oil saturation reaching 1- ⁇ ⁇ .
  • it is possible to estimate ⁇ ⁇ , v and ⁇ ⁇ 1 under borehole conditions, via the polarization characteristics ⁇ ⁇ , ⁇ 0 , ⁇ , ⁇ , ⁇ .
  • Any current value of ⁇ may help compare oil fraction (percent) in a water- and oil-saturated porous reservoir using equations (25), and porosity may be determined from the tabulated curve.
  • FIG. 10 is a flow chart of one method 1000 for estimating changes in oil fraction in the water-oil reservoir and its porosity according to one embodiment of the present disclosure.
  • electromagnetic tool 51A is conveyed in the borehole 12.
  • signals at a plurality of frequencies are transmitted from transmitters 101A, 101B into the earth formation. In some embodiments, at least one of the plurality of frequencies may be at a frequency at or above 500 MHz.
  • receivers 103A, 103B generate an output indicative the complex dielectric permittivity of the earth formation 13.
  • one or more of an oil saturation parameter and a water saturation parameter for a complete saturation point are estimated using the generated output.
  • step 1050 at least one of the formation porosity, the water fraction, and the oil fraction are estimated using the estimated parameters, ⁇ ⁇ and ⁇ ⁇ .
  • the parameters ⁇ ⁇ and ⁇ ⁇ are estimated using an output in the form of a H192iak-Negami polarization curve, such as with sandstone.
  • a Havriliak-Negami polarization curve such as with sandstone.
  • polarization curves may be used depending on lithology, such as, but not limited to, the Cole-Davidson polarization curve.
  • the method in accordance with the presently disclosed embodiment of the disclosure involves several computational steps. As would be apparent by persons of ordinary skill, these steps may be performed by computational means such as a computer, or may be performed manually by an analyst, or by some combination thereof. As an example, where the disclosed embodiment calls for selection of measured values having certain characteristics, it would be apparent to those of ordinary skill in the art that such comparison could be performed based upon a subjective assessment by an analyst or by computational assessment by a computer system properly programmed to perform such a function. To the extent that the present disclosure is implemented utilizing computer equipment to perform one or more functions, it is believed that programming computer equipment to perform these steps would be a matter of routine engineering to persons of ordinary skill in the art having the benefit of the present disclosure.
  • Implicit in the processing of the acquired data is the use of a computer program implemented on a suitable computational platform (dedicated or general purpose) and embodied in a suitable machine readable medium that enables the processor to perform the control and processing.
  • processor as used in the present disclosure is intended to encompass such devices as microcontrollers, microprocessors, field-programmable gate arrays (FPGAs) and the storage medium may include ROM, RAM, EPROM, EAROM, solid-state disk, optical media, magnetic media and other media and/or storage mechanisms as may be deemed appropriate.
  • processing and control functions may be performed downhole, at the surface, or in both locations.

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Claims (12)

  1. Procédé d'évaluation d'une formation terrestre incluant un milieu poreux, le procédé comprenant :
    la réalisation d'une pluralité d'estimations de permittivité complexe, à l'aide d'au moins un processeur, en fonction de mesures en utilisant un outil électromagnétique (10) à une pluralité de fréquences dans un trou de forage (12) pénétrant dans la formation terrestre ;
    l'estimation, à l'aide de l'au moins un processeur, d'au moins un paramètre de polarisation en utilisant une partie réelle et une partie imaginaire de chaque estimation de permittivité complexe de la formation terrestre, où l'au moins un paramètre de polarisation comprend au moins l'un d'un paramètre de saturation d'huile et d'un paramètre de saturation d'eau pour un point de saturation complet (β*, α*) ;
    dans lequel l'utilisation de la partie réelle et de la partie imaginaire comprend la modélisation de la permittivité sous la forme d'une courbe de Havriliak-Negami, l'estimation d'une pluralité de caractéristiques spectrales de la courbe de Havriliak-Negami, et l'utilisation d'une constante de courbe diélectrique spectrale v = 2 ε " max / ε 0 − ε ∞
    Figure imgb0040
    pour le support poreux, la constante de courbe diélectrique spectrale (v) ne variant pas par rapport au ratio eau-huile dans le milieu poreux, où ε " max est le facteur de perte maximum, ε0 est la valeur statique de la partie réelle de la permittivité diélectrique et ε∞ est la limite haute fréquence de la partie réelle de la permittivité diélectrique ; et
    l'estimation, à l'aide de l'au moins un processeur, d'au moins une propriété de la formation terrestre en utilisant l'au moins un paramètre de polarisation, où l'au moins une propriété inclut au moins l'une d'une porosité de formation, d'une fraction d'eau, et d'une fraction d'huile.
  2. Procédé selon la revendication 1, dans lequel la constante de courbe diélectrique spectrale (v) est calculée en utilisant une valeur imaginaire maximale pour la courbe diélectrique spectrale et des valeurs asymptotiques
    (ε = ε 0 , ε = ε ∞) pour les parties réelles de chaque estimation de la courbe diélectrique spectrale.
  3. Procédé selon la revendication 1, comprenant l'utilisation d'un modèle mettant en corrélation la pluralité d'estimations avec la courbe de relaxation de Havriliak-Negami pour déterminer une valeur pour au moins un paramètre de polarisation associé à la courbe.
  4. Procédé selon la revendication 3, dans lequel l'au moins un paramètre de polarisation comprend β, où β se rapporte à un degré de saturation du milieu poreux avec l'huile en la présence d'eau, et la valeur de β comprend β0.
  5. Procédé selon la revendication 4, comprenant la détermination de la valeur de β à l'aide d'un angle d'intersection (ϕ) de deux courbes Im ε = Φ(Re ε) et Im ε = 0 au point où ε = ε 0 et un second angle d'intersection (Ψ) des deux courbes Im ε = Φ(Re ε) et Im ε = 0 au point où ε = ε∞.
  6. Procédé selon la revendication 4, comprenant la modélisation d'un autre paramètre de polarisation α en fonction de la constante de courbe diélectrique spectrale (v) et de la valeur de β, dans lequel α se rapporte à un degré de saturation du milieu poreux avec de l'eau, et dans lequel α se rapporte à un angle de polarisation.
  7. Procédé selon la revendication 6, comprenant la détermination d'une valeur α* de l'autre paramètre de polarisation correspondant à une seconde valeur de β corrélée avec un état exempt d'huile du milieu poreux.
  8. Procédé selon la revendication 7, comprenant l'utilisation des valeurs α et α* pour estimer une fraction d'eau en vrac du milieu poreux ; et/ou
    l'utilisation des valeurs α et α* pour estimer une fraction d'huile en vrac du milieu poreux.
  9. Procédé selon la revendication 6, comprenant la détermination d'une valeur β* du paramètre de polarisation correspondant à une valeur de α corrélée avec un état exempt d'eau du milieu poreux.
  10. Procédé selon la revendication 4, comprenant :
    la détermination d'une valeur β* en utilisant une relation définissant β* en fonction de a, où β* correspond à une valeur de α corrélée avec un état exempt d'eau du milieu poreux ; et comprenant au moins l'une des étapes suivantes :
    l'utilisation des valeurs β et β* pour estimer une fraction d'huile en vrac du milieu poreux ; ou
    l'utilisation de la valeur β* pour estimer une porosité du milieu poreux.
  11. Procédé selon la revendication 1, comprenant en outre l'utilisation de l'outil électromagnétique pour réaliser les mesures à la pluralité de fréquences.
  12. Appareil pour évaluer une formation terrestre incluant un milieu poreux, l'appareil comprenant :
    un support configuré pour être transporté dans un trou de forage (12) pénétrant dans la formation terrestre ;
    un outil électromagnétique (10) disposé sur le support et configuré pour réaliser des mesures indiquant une permittivité complexe de la formation terrestre à une pluralité de fréquences ; et
    caractérisé par au moins un processeur configuré pour :
    réaliser une pluralité d'estimations de permittivité complexe, en fonction de mesures effectuées en utilisant l'outil électromagnétique (10) à une pluralité de fréquences dans un trou de forage (12) pénétrant dans la formation terrestre ;
    estimer au moins un paramètre de polarisation en utilisant une partie réelle et une partie imaginaire de chaque estimation de permittivité complexe de la formation terrestre,
    dans lequel l'au moins un paramètre de polarisation comprend au moins l'un d'un paramètre de saturation d'huile et d'un paramètre de saturation d'eau pour un point de saturation complet (β*, α*) ;
    dans lequel l'utilisation de la partie réelle et de la partie imaginaire comprend la modélisation de la permittivité sous la forme d'une courbe de Havriliak-Negami, l'estimation d'une pluralité de caractéristiques spectrales de la courbe de Havriliak-Negami, et l'utilisation d'une constante de courbe diélectrique spectrale v = 2 ε " max / ε 0 − ε ∞
    Figure imgb0041
    pour le support poreux, la constante de courbe diélectrique spectrale (v) ne variant pas par rapport au ratio eau-huile dans le milieu poreux, où ε " max est le facteur de perte maximum, ε0 est la valeur statique de la partie réelle de la permittivité diélectrique et ε∞ est la limite haute fréquence de la partie réelle de la permittivité diélectrique ; et
    estimer au moins une propriété de la formation terrestre en utilisant l'au moins un paramètre de polarisation, dans lequel l'au moins une propriété inclut au moins l'une d'une porosité de formation, d'une fraction d'eau, et d'une fraction d'huile.
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EP3204798B1 (fr) 2014-10-08 2022-09-28 Baker Hughes Holdings LLC Recherche d'une fraction d'hydrocarbures combinée et de la porosité par spectroscopie diélectrique
CN105116456B (zh) * 2015-07-23 2018-02-13 吉林大学 一种对地下目标的结构和极化属性的联合成像方法
US10317558B2 (en) 2017-03-14 2019-06-11 Saudi Arabian Oil Company EMU impulse antenna
US10365393B2 (en) 2017-11-07 2019-07-30 Saudi Arabian Oil Company Giant dielectric nanoparticles as high contrast agents for electromagnetic (EM) fluids imaging in an oil reservoir

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US7376514B2 (en) * 2005-09-12 2008-05-20 Schlumberger Technology Corporation Method for determining properties of earth formations using dielectric permittivity measurements
CA2833719C (fr) * 2011-04-18 2016-10-18 Halliburton Energy Services, Inc. Procedes et systemes pour estimer une resistivite et une porosite de formation
WO2013012349A1 (fr) 2011-07-18 2013-01-24 Baker Hughes Incorporated Découverte du contenu de pétrole d'une formation à l'aide d'une spectroscopie diélectrique
WO2014014372A1 (fr) 2012-07-16 2014-01-23 Baker Hughes Incorporated Détermination de la viscosité et de la tension superficielle du pétrole par spectroscopie diélectrique
EP3204798B1 (fr) * 2014-10-08 2022-09-28 Baker Hughes Holdings LLC Recherche d'une fraction d'hydrocarbures combinée et de la porosité par spectroscopie diélectrique

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